Method of measuring rock wettability by means of nuclear magnetic resonance

ABSTRACT

Method for measuring the wettability of rocks by low-field nuclear magnetic resonance.  
     The method essentially comprises determining the water wet pore surface and the oil wet pore surface when the sample is saturated with water and oil, by measurements of relaxation times (T 1 , T 2 ) of the sample placed in a nuclear magnetic resonance device, previously brought to various water or oil saturation states, and calculating the wettability index by combination of the values obtained for said surfaces. Application: hydrocarbon reservoir engineering or development, or in civil engineering, etc.

FIELD OF THE INVENTION

The present invention relates to a method for measuring the wettability of rock samples by measuring the relaxation time by low-field nuclear magnetic resonance.

The method finds applications notably for analysis of rocks taken from an underground formation containing or likely to contain hydrocarbons.

Knowledge of various parameters, and notably of the wettability of the rocks, is also useful notably for enhanced recovery of a formation, by injection of a fluid under pressure, and when the fluid (liquid or gas) best suited for effluents displacement is to be determined by means of preliminary tests.

The invention also finds applications in civil engineering for formation hydrology in order to evaluate the degree of pollution of formations for example, or in the building trade for testing building materials notably in order to determine waterproofing treatments for example.

BACKGROUND OF THE INVENTION

There are well-known methods for determining the wettability of rocks to the water and oil that they may contain, comprising carrying out rock drainage cycles, i.e. displacement of fluids intended to decrease the water saturation, followed by imbibition, this term relating to a displacement of the fluids allowing to increase the water saturation (Sw) of the rock. The capillary pressure Pc at one point is defined as the difference at equilibrium between the pressure P(oil) of the oil and the pressure P(water) of the water. This parameter makes sense only if the two fluids are in the continuous phase in the porous medium. For a water wet medium, only the positive values make sense. On the other hand, when the medium has a mixed wettability, the fluids can remain in the continuous phase for the positive as well as for the negative capillary pressures (Pc).

For an application of this type, a complete capillary pressure measuring cycle generally comprises (FIG. 1):

-   -   a) positive primary drainage of an initially 100%         water-saturated sample (curve 1);     -   b) positive imbibition (curve 2);     -   c) negative imbibition (curve 3);     -   d) negative drainage (curve 4); and     -   e) positive secondary drainage (curve 5).

There are various types of devices allowing the curves of FIG. 1 to be drawn.

In a device referred to as <<porous plate>> device, notably described in patent U.S. Pat. No. 4,506,542, the porous rock sample containing two fluids in the continuous phase is placed in an elongate cell ended at its two opposite ends by capillary barriers permeable to a first fluid. This first fluid is injected under pressure through the first membrane and the pressure difference between the injection pressure and the pressure of the fluid discharged at the other end is measured. The pressures of the two fluids and the capillary pressure Pc are constant all along the sample, and the saturation is assumed to be uniform.

It is also known to carry out progressive-speed centrifugation by means of centrifugation devices such as those described for example in patents FR-2,772,477 (U.S. Pat. No. 6,185,985) or FR-2,763,690, or in patents EP-603,040 (U.S. Pat. No. 5,463,894) or FR-2,798,734 filed by the applicant.

The sample initially saturated with a first liquid (brine for example) is placed (FIG. 10) in an elongate vessel or cup A containing a second fluid of different density (oil for example). Cup A is fastened to the end of a rotating arm B and a centrifugal force is applied thereto so as to study the displacements of the fluids in the sample during at least two distinct stages. During a first drainage stage, the assembly is then subjected to a centrifugal force applied along the length of the vessel so as to exert on it an expulsion force which tends to cause part of the first fluid to flow out. The pressure field created by centrifugation is expressed as a function of the density ρ, of the radius R and of the angular velocity w, by the relation: ½w²**. ρ(Rmax²−R²), for each fluid. We impose that the pressure of the two fluids at the sample outlet is the same and is equal to zero at the outlet. At the same time, the second fluid flows into the sample. The two fluids move in the sample until a position of equilibrium is reached where the force due to the capillary pressure in the pores compensates the centrifugal force exerted. A measuring sonde is placed in the cup on the side of the sample. The sonde can be of capacitive type for example and comprise a metal rod insulated by a ceramic sheath. The capacity between the rod and the conducting fluid (brine), which is proportional to the immersed height, is measured. With this measuring means, the measuring accuracy is 1.5% of the pore volume. The sonde detects the position of the interface between the two liquids in the cup and transmits the measuring signals to a measuring signal acquisition and control automaton E including hydraulic liquid circulation means and an acquisition device.

During the re-imbibition stage, the velocity is decreased so as to study the return of the initial fluid into the sample. The local saturations measured with this type of device are calculated by an inversion programme from the total amount of water expelled from the sample.

According to another method, referred to as <<dynamic>> method, a sample is placed in an elongate cell ended at its two ends by water-permeable membranes. At a first end, oil under pressure is directly injected into the enclosure. Water is also injected, but this injection is carried out through the membrane and at a lower pressure. At the opposite end, the oil is directly discharged whereas the water flows out through the terminal membrane. Adjustment of the oil and water injection rates allows the capillary pressure to be the same at the inlet and at the outlet of the enclosure, which leads to a uniform saturation that can be deduced from the fluids balance. The capillary pressure is obtained for example by measuring the difference between the pressure of the oil and of the water at the enclosure outlet. Such a method is notably described by Brown H. W. in <<Capillary Pressure Investigations>>, Petroleum Transaction AIME, vol. 192, 1951. Examples of implementation are for example described in patents EP-729,022 (U.S. Pat. No. 5,698,772) or EP-A-974,839 (U.S. Pat. No. 6,229,312) filed by the applicant.

A method referred to as semi-dynamic method is also known, wherein a rock sample imbibed with a first fluid is confined in a closed cell, another fluid under pressure is injected at a first end of the enclosure and the opposite end is swept by a low-pressure fluid circulated by pumping means which carries the drained fluid outside. The device comprises means for measuring the pressure and the saturation of the sample, the amount of fluid discharged and the electric resistivity of the sample. This method is implemented for example in patent FR-2,708,742 (U.S. Pat. No. 5,679,885) filed by the applicant.

These drainage and imbibition curves being established, it is well-known to calculate the wettability indices WI from the surface areas Ad and Ai delimited by the positive and negative capillary pressure curves, as shown in FIG. 1, by the relation ${WI}_{({USBM})} = {{Log}\quad{\frac{A_{d}}{A_{i}}.}}$

SUMMARY OF THE INVENTION

The method for measuring the wettability of a porous rock sample in the presence of water and oil according to the invention comprises determining the water wet pore surface and the oil wet pore surface when the sample is saturated with water and oil, and calculating the wettability index by combination of the values obtained for said surfaces.

Determination of the water wet pore surface and of the oil wet pore surface when the sample is saturated with water and oil is obtained for example by means of measurements of relaxation times of the sample placed in a nuclear magnetic resonance device.

The wettability index is for example determined by the relation: $I_{NMR} = {{\frac{{SM}_{w} - {SM}_{o}}{{SM}_{w} + {SM}_{o}}\quad{or}\quad{the}\quad{relation}\quad I_{NMR}} = {\log_{10}\frac{{SM}_{w}}{{SM}_{o}}}}$ where SM_(w) is the water wet pore surface and SM_(o) is the oil wet pore surface when the porous medium is saturated with water and oil.

According to an implementation mode, the wettability index is determined by the following operations:

-   -   a) measuring the characteristic relaxation times of the         water-saturated sample;     -   b) measuring the characteristic relaxation times of the oil in         the sample in the presence of water, in a zone close to         saturation (Swir) of the sample;     -   c) measuring the characteristic relaxation times of the water in         the sample in the presence of oil, in a zone close to residual         saturation (Sor);     -   d) measuring the relaxation times of the sample in a state where         its 100% oil saturation point is reached; and     -   e) combining the measurements of the various relaxation times so         as to obtain said index.

According to a preferred implementation mode, the relaxation times of stages a) to c) are determined after subjecting the sample to centrifugation.

According to a preferred implementation mode, the relaxation times of stage d) are determined after forced displacement of the fluids in the sample placed in a containment cell.

An oil whose intrinsic relaxation time (T_(B)) is as great as possible and as close as possible to that of water, dodecane for example, is preferably selected.

The characteristic relaxation times are for example those corrresponding to either the saturation curves maxima, or to mean values of said curves.

Experience shows that the measurement of I_(NMR) obtained by means of the method is as sensitive but that it requires much less time and that it is applicable to a large number of samples.

BRIEF DESCRIPTION OF THE FIGURES

Other features and advantages of the method and of the device according to the invention will be clear from reading the description hereafter of an embodiment given by way of non limitative example, with reference to the accompanying drawings wherein:

FIG. 1 shows examples of capillary pressure curves necessary for determination of the conventional wettability index I_(USBM) (United States Bureau of Mines),

FIGS. 2 a and 2 b respectively show the distribution of relaxation times T₂ for a water wet rock saturated with water and oil, and a representation of the phase distribution (matrix in hatched lines, water in light grey and oil in darker grey),

FIGS. 3 a and 3 b respectively show the distribution of relaxation times T₂ for a rock of intermediate wettability saturated with water and oil (same central part as in FIG. 2), and a representation of the phase distribution (matrix in hatched lines, water in light grey and oil in darker grey),

FIG. 4 shows, on capillary pressure curves, the saturation values where the NMR relaxation measurements are performed,

FIG. 5 shows an example of distribution of relaxation times T₂ at the saturation values given in FIG. 4 (from the bottom up: 100% water, Swi, Sor and 100% dodecane),

FIG. 6 shows the relation between-index I_(NMR) and the standard index I_(USBM),

FIG. 7 diagrammatically shows a containment cell with a permanent heating circuit by fluid circulation, and

FIG. 8 diagrammatically shows the layout of a centrifugation device used for implementing the method.

DETAILED DESCRIPTION

It may be reminded that the NMR analysis technique essentially consists in applying to an object to be tested a first static magnetic polarization field Bo intended to align the initially randomly oriented hydrogen protons nuclei in the direction of the field, then a second impulsive magnetic field oscillating at the Larmor frequency, perpendicular to the first one, created by coils excited by a control signal to carry out a nuclear magnetic resonance experiment. When this impulsive field stops, the return of the nuclei to their initial state or relaxation generates electromagnetic signals (echoes) which are detected and analyzed. The presence of physical parameters of the object is determined from the amplitude characteristics of these signals.

We propose defining a new wettability index constructed by combining values of the water wet pore surface SM_(w) and of the oil wet pore surface SM_(o) when the porous medium is saturated with water and oil. The index can be calculated for example by the relation as follows: $\begin{matrix} {I_{NMR} = \frac{{SM}_{w} - {SM}_{o}}{{SM}_{w} + {SM}_{o}}} & \left( {1a} \right) \end{matrix}$ or by the relation: $\begin{matrix} {I_{NMR} = {\log_{10}\frac{{SM}_{w}}{{SM}_{o}}}} & \left( {1b} \right) \end{matrix}$

Quantities SM_(w) and SM_(o) are obtained for example by measuring the dominant relaxation time in a low-field nuclear magnetic resonance experiment.

In fact, in such an experiment, the fundamental relation connecting the longitudinal T₁ or transverse T₂ relaxation time to surface S and to the volume of this pore is as follows: $\begin{matrix} {\frac{1}{T_{1,2}} = {\frac{1}{T_{{1B},{2B}}} + {\rho_{1,2}\frac{S}{V}}}} & (2) \end{matrix}$ where T_(1B,2B) is the relaxation time of the fluid outside the porous medium. Basically, this relation comes from the fact that the molecules in the pore undergo diffusion motions and interact with the porous wall during the measuring time (the typical relaxation time is of the order of 100 ms). The surface interactions are designated by coefficient ρ_(1,2) referred to as surface relaxivity. Besides, we have disregarded a gradient term that is important when measurements are performed at a high magnetic field (>0.1 T). Relation 2 is strictly valid for a pore saturated with a single fluid. In general, natural porous media have a pore size and therefore ratio S/V distribution. A relaxation times distribution is thus generally observed, but this does not modify the method described here.

When two fluids are present in a pore within the porous medium, the same physical diffusion mechanism is valid, but the distribution of the two fluids in relation to the pore surface is of crucial importance. For example, when the medium is water wet, the water is at the surface and interacts therewith, whereas the oil is inside the pore and does not interact with the surface. When the distribution of the relaxation times is measured for such a system, the result of FIG. 2 a is observed. The water has shorter relaxation times than in the case of a 100% water saturation, because the volume of water V has decreased (see equation 1). The oil is characterized by a relaxation time that is the same as when the measurement is performed outside the porous medium (T_(1B,2B)) because there is no interaction with the pore surface. Besides, it is well-known that interactions at the water/oil interface do not lead to a relaxation that is different from that of the oil outside the porous medium, provided that the oil considered is light (refined oil such as dodecane). Diagrammatically, the phase distribution is shown in FIG. 2 b. When the same porous medium has a different wettability and is not clearly water wet, the distribution of the relaxation times is modified (FIG. 3 a). Essentially, the characteristic time of the oil will be shorter as a result of an interaction of the oil at the pore surface because the water is no longer the closer to the surface. The possible distribution of the two fluids is shown in FIG. 3 b. Such an effect has been obtained using standard procedures allowing to reproduce the surface properties of rocks from a petroleum reservoir: cleaning, then aging in the reservoir oil at the temperature of the reservoir at the irreducible water saturation.

We thus generalize relation (2) to a two-phase water-oil system. For the water, we have: $\begin{matrix} {\frac{1}{T_{{1w},{2w}}} = {\frac{1}{T_{{1{Bw}},{2{Bw}}}} + {\rho_{{1w},{2w}}\frac{{SM}_{w}}{V_{w}}}}} & (3) \end{matrix}$ and for the oil: $\begin{matrix} {\frac{1}{T_{{1o},{2o}}} = {\frac{1}{T_{{1{Bo}},{2{Bo}}}} + {\rho_{{1o},{2o}}{\frac{{SM}_{o}}{V_{o}}.}}}} & (4) \end{matrix}$

We can thus determine quantities SM_(w) and SM_(o) by measuring relaxation times T₁ or T₂ in the porous medium, relaxation times T_(1B) or T_(2B) of the fluids outside the porous medium, liquid volumes V_(o) or V_(w) present in the porous medium The interaction constants ρ can be determined separately, but we will see that only the ratio of these constants is necessary.

If we introduce relations 3 and 4 in base relation 1, we obtain: $\begin{matrix} {I_{NMR} = \frac{{{Sw}\left( {\frac{1}{T_{w}} - \frac{1}{T_{bw}}} \right)} - {C\quad\rho\quad{{So}\left( {\frac{1}{T_{o}} - \frac{1}{T_{bo}}} \right)}}}{{{Sw}\left( {\frac{1}{T_{w}} - \frac{1}{T_{bw}}} \right)} + {C\quad\rho\quad{{So}\left( {\frac{1}{T_{o}} - \frac{1}{T_{bo}}} \right)}}}} & (5) \end{matrix}$

-   -   where Sw=Vw/Vp is the water saturation,     -   So=Vo/Vp is the oil saturation, and     -   Vp the pore volume. ${C\quad\rho} = \frac{\rho_{w}}{\rho_{o}}$         is the ratio of the relaxivities for the water wet (w) and oil         wet (o) surfaces. To simplify the notation, indices 1 and 2 have         been suppressed.

The most suitable saturations for measuring quantities SM_(w) and SM_(o) thus remain to be determined. For reasons linked with the calculation of the relaxation time distributions, we select the irreducible water saturation (Swi, FIG. 4) to determine the oil wet surface in the presence of water (SM_(w)), and the residual oil saturation (Sor, FIG. 4) to determine the water wet surface in the presence of oil. We also select an oil whose intrinsic relaxation time (T_(B)) is as great as possible and as close as possible to water. In fact, if T_(B) is too small, the method will be limited to porous media whose ratio S/V is high (small pore sizes), or to media whose surface relaxivity is high. Dodecane for example is a refined oil which is suited to the proposed measurement because its intrinsic relaxation time (T_(Bo)) is 1 s, close to the relaxation time of water (T_(Bw), about 2.7 s). Crude petroleum oils should generally not be used because their relaxation times are too small and they also have a relaxation time distribution which considerably hinders analysis. The practical details of the calculation are given below.

From the distribution of the relaxation times at the different saturations (see the example of FIG. 5), the relaxation time corresponding to the dominant peak (Tw at Sor, To at Swi) can be easily determined, and these values are used in relation 5. It is well-known that determination of the dominant relaxation time is robust and depends little on the distribution calculation process. It can be noted that the dominant peak corresponds to that of the oil at Swi and of the water at Sor. The presence of the second fluid at these different saturations is important from a physical point of view, but it disturbs calculation very little. We can show that whatever the relaxation time of the second fluid present in small amount (water at Swi, oil at Sor), the relaxation time of the dominant fluid does not fluctuate much. This aspect is important for the calculation robustness. FIG. 5 shows the distribution of the transverse relaxation times T₂. The longitudinal relaxation time T₁ can also be used, but this measurement is less favourable in general because T₁>T₂ but T_(1B)=T_(2B) for a given fluid.

In order to determine the surface relaxivity ratio Cρ, we use the dominant relaxation times T_(w100) and T_(o100) respectively at the two saturations Sw=100% and So=100%. The formula used is as follows: $\begin{matrix} {C_{\rho} = {\frac{\rho_{w}}{\rho_{o}} = {\frac{{1/T_{w100}} - {1/T_{Bw}}}{{1/T_{o100}} - {1/T_{Bo}}}.}}} & (6) \end{matrix}$

FIG. 5 illustrates the two measurements performed. Thus, in total, the relaxation times distributions have to be measured at four saturations: 100% brine, 100% oil and the extreme saturations Swi and Sor. We can therefore use the centrifugation technique to reach, starting from Sw=100%, Swi, then Sor. A single rotation stage at maximum speed allows these values to be rapidly reached. For measurement at So=100%, we use a succession of miscible displacements by injecting an alcohol, then the refined oil.

Implementation

For implementing the method, we use for example an NMR measuring device conventionally comprising (FIG. 7) magnets 1 with an air gap in which coils 2 are arranged. The coils are connected to an electronic box to generate the excitation signals (signals in the radiofrequency range for example) creating an oscillating electric field and to acquire the response of sample S to the excitation signals. A device of this type is used for example in patent application FR-A-2,823,308.

Practical Implementation Example

The wettability index is obtained by carrying out for example the following succession of stages with a reservoir sample whose wettability is intermediate:

1. The sample is 100% saturated with reservoir brine and placed in the NMR measuring device (as shown in FIGS. 7-8 for example) to measure the distributions of relaxation times T₁, T₂ and to deduce parameter Tw100 of equation 6;

2. It is then placed in the centrifugation device (as schematized in FIG. 10) and centrifuged at maximum speed in a vessel filled with oil until the irreducible water saturation Swir is reached; the distributions of relaxation times T₁, T₂ are then measured in the NMR device so as to deduce T_(o) of equation 5;

3. After being placed again in the centrifugation device, the sample is centrifuged at maximum speed until the residual oil saturation Sor is reached; it is then transferred into the NMR device again to measure relaxation times T₁, T₂ and to deduce T_(w);

4. The sample is thereafter placed in a containment cell such as those described in the aforementioned patents and a water and oil miscible solvent, then oil (dodecane for example) is injected until the 100% oil saturation is reached. This point being reached, relaxation times T₁, T₂ are again measured in the NMR device and the value of T_(o100) required for determination of C_(ρ) is deduced.

We thus know all the parameters for calculation of wettability coefficient I_(NMR).

Comparison with Index I_(USBM)

Comparison between wettability index I_(USBM) and the new index I_(NMR) shows a good correlation between these two quantities (FIG. 6) for reservoir rocks. The measurement of I_(USBM) can therefore be advantageously replaced by a measurement of I_(NMR), which is as sensitive but requires much less time and is applicable to a large number of samples.

We have described an implementation example where a NMR type relaxometry method is used to measure the surface and the volume of the pores. This method is however not limitative. Any other analysis method can be used, notably cryomicroscopy. 

1) A method for measuring the wettability of a porous rock sample in the presence of water and oil, characterized in that it comprises determining the water wet pore surface and the oil wet pore surface when the sample is saturated with water and oil, and calculating the wettability index by combination of the values obtained for said surfaces. 2) A method as claimed in claim 1, characterized in that determination of the water wet pore surface and of the oil wet pore surface when the sample is saturated with water and oil is obtained by means of measurements of relaxation times (T₁, T₂) of the sample placed in a nuclear magnetic resonance device. 3) A method as claimed in claim 1, characterized in that the wettability index is obtained by the relation: $I_{NMR} = \frac{{SM}_{w} - {SM}_{o}}{{SM}_{w} + {SM}_{o}}$ where SM_(w) is the water wet pore surface and SM_(o) is the oil wet pore surface when the porous medium is saturated with water and oil. 4) A method as claimed in claim 1, characterized in that the wettability index is obtained by the relation: $I_{NMR} = {\log_{10}\frac{{SM}_{w}}{{SM}_{o}}}$ where SM_(w) is the water wet pore surface and SM_(o) is the oil wet pore surface when the porous medium is saturated with water and oil. 5) A method as claimed in claim 1, characterized in that the wettability index is determined by the following operations: a) measuring the characteristic relaxation times of the water-saturated sample; b) measuring the characteristic relaxation times of the oil in the sample in the presence of water, in a zone close to saturation (Swir) of the sample; c) measuring the characteristic relaxation times of the water in the sample in the presence of oil, in a zone close to residual saturation (Sor); d) measuring the relaxation times of the sample in a state where its 100% oil saturation point is reached; and e) combining the measurements of the various relaxation times so as to obtain said index. 6) A method as claimed in claim 5, characterized in that the relaxation times of stages a) to c) are measured after subjecting the sample to centrifugation. 7) A method as claimed in claim 5, characterized in that the relaxation times of stage d) are measured after forced displacement of the fluids in the sample placed in a containment cell. 8) A method as claimed in claim 1, characterized in that an oil whose intrinsic relaxation time (T_(B)) is as great as possible and as close as possible to that of the water is selected. 9) A method as claimed in claim 5, characterized in that the characteristic relaxation times are those corresponding to either the saturation curves maxima, or to mean values of said curves. 10) A method as claimed in claim 1, characterized in that the weltability index is obtained by the relation: $I_{NMR} = \frac{{SM}_{w} - {SM}_{o}}{{SM}_{w} + {SM}_{o}}$ where SM_(w) is the water wet pore surface and SM_(o) is the oil wet pore surface when the porous medium is saturated with water and oil. 11) A method as claimed in claim 2, characterized in that the wettability index is obtained by the relation: $I_{NMR} = {\log_{10}\frac{{SM}_{w}}{{SM}_{o}}}$ where SM_(w) is the water wet pore surface and SM_(o) is the oil wet pore surface when the porous medium is saturated with water and oil. 12) A method as claimed in claim 2, characterized in that the wettability index is determined by the following operations: f) measuring the characteristic relaxation times of the water-saturated sample; g) measuring the characteristic relaxation times of the oil in the sample in the presence of water, in a zone close to saturation (Swir) of the sample; h) measuring the characteristic relaxation times of the water in the sample in the presence of oil, in a zone close to residual saturation (Sor); i) measuring the relaxation times of the sample in a state where its 100% oil saturation point is reached ; and combining the measurements of the various relaxation times so as to obtain said index. 13) A method as claimed in claim 3, characterized in that the wettability index is determined by the following operations: j) measuring the characteristic relaxation times of the water-saturated sample; k) measuring the characteristic relaxation times of the oil in the sample in the presence of water, in a zone close to saturation (Swir) of the sample; l) measuring the characteristic relaxation times of the water in the sample in the presence of oil, in a zone close to residual saturation (Sor); m) measuring the relaxation times of the sample in a state where its 100% oil saturation point is reached; and combining the measurements of the various relaxation times so as to obtain said index. 14) A method as claimed in claim 4, characterized in that the wettability index is determined by the following operations: n) measuring the characteristic relaxation times of the water-saturated sample; o) measuring the characteristic relaxation times of the oil in the sample in the presence of water, in a zone close to saturation (Swir) of the sample; p) measuring the characteristic relaxation times of the water in the sample in the presence of oil, in a zone close to residual saturation (Sor); q) measuring the relaxation times of the sample in a state where its 100% oil saturation point is reached; and combining the measurements of the various relaxation times so as to obtain said index. 15) A method as claimed in claim 2, characterized in that an oil whose intrinsic relaxation time (T_(B)) is as great as possible and as close as possible to that of the water is selected.
 16. A method as claimed in claim 3, characterized in that an oil whose intrinsic relaxation time (T_(B)) is as great as possible and as close as possible to that of the water is selected.
 17. A method as claimed in claim 4, characterized in that an oil whose intrinsic relaxation time (T_(B)) is as great as possible and as close as possible to that of the water is selected.
 18. A method as claimed in claim 5, characterized in that an oil whose intrinsic relaxation time (T_(B)) is as great as possible and as close as possible to that of the water is selected.
 19. A method as claimed in claim 6, characterized in that an oil whose intrinsic relaxation time (T_(B)) is as great as possible and as close as possible to that of the water is selected.
 20. A method as claimed in claim 7, characterized in that an oil whose intrinsic relaxation time (T_(B)) is as great as possible and as close as possible to that of the water is selected. 